Home

New York Independent System Operator Request for

Contents

1. and viii The Long Island Lighting Company d b a LIPA a subsidiary of the Long Island Power Authority a corporate municipal instrumentality of the State of New York LIPA through its agent National Grid Electric Services LLC d b a National Grid 1 3 System Overview This Project will provide the foundation for and enable future developments of a smart grid infrastructure SGI in the New York bulk electric system BES The objective of the Project is to enhance the reliability of the New York Control Area s NYCA s BES and to improve the efficiency of the New York power delivery system The Project is comprised of three parallel tracks One of the Project tracks will deploy a statewide open flexible interoperable secure and expandable PMN system that will work in concert with the existing control and monitoring systems The PMN system will operate using standard information models and communication protocols The PMN system will enhance the ability to detect system vulnerabilities and disturbances in real time and to potentially mitigate their impact The scope of work associated with this Project track involves the installation of PMUs by each of the TOs within their respective transmission districts and the integration of those devices with their energy control centers and the NYISO s control centers The TOs intend to engage multiple vendors to purchase install and integrate their PMUs with the PMN In the second
2. 113 Trending capability Yes No 114 Pan and zoom capability Yes No 115 Tabular displays with real time updates of synchrophasor data Yes No 116 Ability to distinguish the data in the displays by the data sources historical data from archive calculated values originated PDC PMU device signal etc Yes No 117 Ability to serve displays in remote user stations via the Internet Yes No 118 User report definition capability Yes No 41 NEW YORK INDEPENDENT SYSTEM OPERATOR 120 121 122 123 horizontal option through selection panels for 124 Selective alarm parameter for individual PMUs Yes No Alarm filtering grouping and alarm report generation capability Yes No Pop up or flash feature on receipt of a significant alarm Yes No Alarm acknowledgment capability Yes No Ability to display phasor and frequency plots in tiled windows with vertical and Voltage Phase Angle Graphs Yes No Voltage Graphs Yes No Reference Voltage Phase Angle Yes No Frequency Graphs Yes No Current Phasor Graphs Yes No Active Power Flow Graphs Yes No Reactive Power Flow Graphs Yes No Af At Graph Yes No Path Active Power Graphs Yes No Path Reactive Power Graphs Yes No Path Current Graphs Yes No Graphs not limited to Frequency Plot Yes No Voltage Plot Yes No Current Plot Yes No Polar phase angle plot Yes No Rectangular phase angle plot Yes No Active Power Plot Yes No
3. 6 DFR should interface with external PMU DFRS and PDCs and eventually Data Management Yes No Vendor s system should conform to the input output and services specified below 7 DER Input a b C Triggers received from other DFR PMUs and or Global Event Record Trigger Management Applications Yes No Requests to send recorded data to SDM servers Yes No NYISO Phasor Gateway Future Yes No 8 DFR Output a b Recorded data to SDM servers Yes No NYISO Phasor Gateway Future Yes No 9 DER Services a Transient and long term events can be acquired by any triggered event when one of the user programmable trigger thresholds is exceeded The available triggers must include Over magnitude Yes No Under magnitude Yes No Absolute Angle Local vs Remote Yes No Absolute frequency deviation from 60 Hz Yes No Rate of change of frequency Yes No Digital change of state Yes No Linear combination of magnitude frequency and rate of change of frequency Yes No Manual local and remote Yes No 21 NEW YORK INDEPENDENT SYSTEM OPERATOR B 2 j Cross trig by neighboring units Yes No k Global trig by Global Event Trigger management application Yes No Phasor Measurement Unit PMU Function B 2 1 General PMU Requirements The PMU functions should have at a minimum the following capabilities l The PMU function of NYISO DFR PMU must be able to record electric
4. B 3 11 System Capacity 89 Is the system expandable such that there are no limits on number of input output real time phasor data streams the highest input output phasor data rates the size of input output data packet size and the number of processing functions that the product can support If not please indicate what could be your product s limits 90 Has the product s system capacity been verified by appropriate tests If yes please provide the information on the performed test and the test results BA PMN Data Processing Data Management and Applications B 4 1 Phasor Data Acquisition and Control PDAC Will the PDAC deployed for SGI support the following data protocols 1 Data Input Format IEEE C37 118 2005 Yes No 2 Data Output Format IEEE C37 118 2005 Yes No 3 IEC 61850 PDAC Input 4 It reads the time tag on incoming PDC and PMU phasor data and places the data in an internal circular buffer functionally The PDC shall have a circular buffer with sufficient length for time alignment of received PDC and or PMU real time data stream In synthesis the PDC correlates phasor data by time tag to create a system wide measurement set Yes No 5 PDAC shall be fully configurable and redundant The system parameters are but not limited to overall system parameters such as data rate size of data table number of CPU boards number of PDCs and number of PMUs Yes No 6 The inputs from PDCs and external PDCs to PDAC m
5. NEW YORK INDEPENDENT SYSTEM OPERATOR New York Independent System Operator Request for Information on Equipment Software amp Systems Integration Services for Statewide Synchronized Phasor Measurement System Wide Area Situational Awareness Applications amp Smart Grid Enabled Capacitor Systems NEW YORK INDEPENDENT SYSTEM OPERATOR Table of Contents 1 0 MAI SOG GONG OE OE ease OE EE AA ees ene mae es 1 Ma RE RO N NE E a 1 12 Abo tth DY IO eebe 1 EN ie oo EE EE OE N OE 2 1 4 Project Concept al EE 3 1 4 1 SGI System Components syirik Di EK EER OR OER EE KG ee EEEN EELE SON E Ne ese 3 1 42 Smart Grid Enabled Capacitor System Component iese esse es see ee ee ee ee 5 1 5 Structure of this Request for Information iese ese se se ee ee RA RR ee ee RA RR ee 5 2 0 System REEN SG SE OG Ge Oe EE eee ca ec a eee 6 2 1 PMN System Requirements SAT Ses eens soes RE SE EE EEN Ge pe eke Di N ed N 6 2 2 SGI System Requirements for Current Deployment iss esse es ss se ee ee ee RA ee Re 6 2 3 SGI System Requirements for Future Expansion lntegrapon sesse sees se ee se ese ee ek ee 6 24A PME AO ii EE EE EE RE EEN 6 241 PME Ge 6 244 Phasor Data Concentrator PDC Fume nots is ee RE ene Ee GR Dk Gee RES 7 2 5 Phasor Data Acquisition and Control PDAC sisie See ese Ge EER Ee ees es GE Ek eN ee ee kke tenes 7 St Application Functions onsidersd sis N ie eN ege 8 3 1 Voltage Phase Angle Monitori
6. What are the license terms and conditions How frequent an upgrade is available What are the inputs and outputs of the WASA application Voltage Stability Does the application provide a module for voltage stability prediction Where does the voltage stability application reside PDC level or Master PDC level How many computer systems are needed What is the memory requirement for the application How much CPU time is used for this application Provide summary of the algorithm used to predict voltage stability At what frequency is the voltage stability algorithm is run i e for each sample of the PMU data or at certain interval 54 NEW YORK INDEPENDENT SYSTEM OPERATOR Does the application need a system model for this application 10 11 12 13 CU 10 11 12 13 14 C 12 Can the application provide PV QV curves for output display Is it possible to select a particular bus or region for voltage stability analysis What communication protocol is used to send or receive data for the application Is the voltage stability application capable of sending or receiving data from any other applications Is it possible to run the voltage stability analysis both online in real time and offline State Estimation EMS What is the minimum time interval between two consecutive state estimation calculations How much is the processor usage for each state estimation calculation
7. How many computer workstations are needed for the application Is the EMS capable of receiving and utilizing PMU data What is the protocol used for data communication between PDC and EMS server Is the EMS capable of multiview graphical user interface GUI Is the EMS interoperable with other vendor s supplies What are the main functionalities of the EMS application Does the application need any data from other applications What communication protocol is used to exchange data between applications What is the cost of the EMS application What are the license terms and conditions How frequent is an upgrade available What are the inputs and outputs of the FRF application Calibration and Validation of NYISO s System Models Does the vendor have an application for calibration and validation of system steady state model 55 NEW YORK INDEPENDENT SYSTEM OPERATOR Does the application need PMU data Does the application need EMS SCADA data Does the application need RTU data What algorithm is used to identify the steady state parameters for NYISO model Can the application be run in real time Calibrate and Validate of NYISO s Dynamic System Models Does the vendor have an application for calibration and validation of system dynamic model What are the main parameters that are validated through the application Does the application need PMU data Does the application need EMS SCADA data Does the ap
8. NYISO grid PDAC subsystems may also receive synchrophasor data from a number of external PDCs through NERCnet ISOnet or NASPInet The PDC NEW YORK INDEPENDENT SYSTEM OPERATOR function of PDAC subsystems correlate the received data according to their time tag generates a time aligned aggregated data stream and feeds the time aligned data either to some application directly or to a Data Management subsystem for more comprehensive data validation and quality check After validation and quality check the data will be streamed to some applications and also stored in the SGI Real Time and Historian databases for use by SGI applications Time aligned data could also be sent to other participating utilities or Independent System Operators in the North East Any utility s data can be identified by the ID for the PDC that is embedded in the data or by device IP address The communication link used for data flow between PDAC and PDCs DFRs PMUs is a secured NYISO IP WAN network IPv6 but may start as IPv4 for SGI and the PMU data packets are transmitted in UPD IP format 3 0 Application Functions Considered SGI will provide a number of wide area analysis control and situational awareness applications to support both real time decision making and post event analysis It is expected that some will reside within the EMS and others will be distributed to reside in that part of the system providing the most efficient use of computational capabili
9. Stability is the ability of an interconnected power system to maintain acceptable voltages at all applicable load buses under normal and abnormal conditions Interconnected systems on the Western Eastern and ERCOT Interconnections comply by meeting North American Electric Reliability Corporation NERC voltage and reactive control reliability standards and system performance planning standards under both normal and contingency conditions NERC balancing areas balance generation and load while ensuring voltage levels reactive flows and reactive resources are monitored and maintained within limits to protect equipment and maintain the reliable operation of the interconnection The goal of the interconnection is to deliver energy to fluctuating loads at applicable buses without allowing the voltage to drop below nominal operating levels If a bus is loaded beyond its limit the system voltage becomes unstable causing circuit breakers to trip This loading limit depends on the system conditions and varies from situation to situation The objective of the voltage stability monitoring application is to provide a real time online tool for assessing the power system reliability margin with respect to voltage stability from phasor measurement data The outcome should assist bulk power operators to take pre emptive remedial measures thereby preventing voltage instability and furthermore voltage collapse linked to cascading failures of the system 3 3 Low Frequency
10. Warning and alarm for growing low frequency oscillation or poor damping with C 4 C 4 1 appropriate identifiable colors and information of the mode Yes No Fault Location Faulted Lines Identification The faulted lines identification function is used to quickly and positively identify the line sections that just experienced either a temporary or permanent fault l C 4 2 The function shall be able to use network breaker switching indication relay operation indication and or DFR notifications to positively identify the faulted lines within 2 seconds after a fault occurrence Yes No The function shall use the results of breakers reclosing operations to indicate whether the fault is a temporary fault or a permanent fault Yes No The function shall indicate whether there were any previous faults on the same line in the last hour last 24 hours last 15 days and last 12 months Yes No The function shall initiate the fault recording retrieval process to retrieve fault records from DFRs for identified faulted line s and then start the fault location calculation function for identified faulted line s Yes No Fault Location Calculation The fault location calculation function is to provide calculated or estimated fault location information for faulted lines after these lines are positively identified 5 The fault location calculation function shall be able to complete the fault location calculation or estimation
11. by the size of data packet of the phasor data streams that it receives from PMUs Does the product have to be stopped for updating PMU PDC configuration changes If not please describe how the product updates PMU PDC configuration changes without stopping its continued operation for TCP IP data streaming and for UDP IP data streaming both unicast and multicast Does the product provide a PMU PDC data stream start stop function to start or stop a data stream from a PMU or PDC If yes please describe how this function is implemented for TCP IP data streaming and UDP IP data streaming both unicast and multicast and the messaging protocol used Data Preprocessing Capabilities 40 41 42 43 44 45 46 Does the product include certain data processing functions in addition to time alignment of received data streams such as data validation data error detection down sampling filtering etc If yes please list all data processing functions and their specifications Are all processing functions for real time data streams performed periodically according to fixed time schedules that are synced to UTC Can the time alignment function of your product create output data streams that maintain original PMU PDC data frame configurations Can the time alignment function of your product create new PMU data configurations in the output data stream that are different from original PMU PDC data frame configurations Does
12. can communicate over Distributed Network Protocol DNP Yes No Products can communicate over Inter Control Center Protocol ICCP Yes No 61 NEW YORK INDEPENDENT SYSTEM OPERATOR Supplemental C Glossary Acronym Description AES Advanced Encryption Standard AGC Automatic Generation Control AMI Advanced metering infrastructure ARRA American Recovery and Reinvestment Act BES Bulk electric system CA Contingency analysis an operational planning tool to analyze impacts of contingencies such as line and terminal outages on the power grid performance CCPDC Control center phasor data concentrator CCS Control center system CES Core Enterprise Services a set of common IT services for multiple information systems and applications in NYISO CIM Common Information model IEC 61970 CIP Critical infrastructure protection C RAS Centralized remedial action scheme where remedial actions are coordinated centrally using high speed data transmission from relays and other IEDs from their field locations to a central engineering station CRC Cyclic redundancy check DA Distribution automation D B A Doing Business As DER Distributed energy resources DFR Digital fault recorder DFRR Digital fault recorder records retrieval DG Distributed generation DME Disturbance monitoring equipment DMS Distribution management sys
13. center may have too much of an administrative task on its hands with perhaps hundreds of PMUs to be handled across the network PDCs also perform the task of hosting any substation level application functions that may need the data from the specific substation and in effect can become a host to a network of distributed application functions identified as Smart Grid capable 2 5 Phasor Data Acquisition and Control PDAC This section focuses on the functionality and data flow requirements of each SGI component in the PDAC subsystems located at the Grid Control Center GCC It is envisioned that some applications requiring a large amount of phasor data may be processed at this level PDAC subsystems receive data streams from substation internal PDCs PMUs and external PDCs The phasor data streams are packets of data representing a sample of system measurements with a time tag applied precisely when the sample was taken The packets are sent continuously via a communication channel to the PDC PDAC subsystem correlates synchrophasor data by time tag to create a system wide time synchronized measurement set PDAC subsystem also provides some simple synchrophasor data quality checks monitors the overall measurement system with performance records and displays Located at the NYISO Control Centers GCC PDAC subsystems will interface with GCC SGI LAN and NYISO SGI WAN to receive synchrophasor data from a number of PDCs DFRs PMUs installed in
14. function is implemented hardware and software To be completed 53 Does data storage support both online data storage for fast retrieval and long term data storage and archive e g historian 54 Is the data storage capacity expandable so that there will be no limit on the amount of data stored 55 Is the product using an open data format for storing and retrieving the data If yes please identify the format If not please describe the format used 56 Does the product provide data retrieval methods for remote retrieval of the stored data If yes please describe each method and the associated data retrieval API and protocols 57 Does the storage function only handle synchrophasor data storage and retrieval If other data are also handled please identify types of data that it also handles and how they are handled Data Management Capabilities 58 Does the product perform certain data validation for received data If yes describe what types of validations are performed and how they are performed 59 Does the product include a data error handling function If yes please describe what types of data errors that it handles and how these errors are handled 31 NEW YORK INDEPENDENT SYSTEM OPERATOR 60 Does the product include a QoS latency interruptions etc monitoring function for received data streams If yes please describe how this function works 61 Does the product provide a missing data retrieval function
15. of system losses 14 Project Conceptual Overview 1 4 1 SGI System Components The functional SGI system configuration overview depicted in Figure 1 shows the major components of the PMN added to the existing operational environment This Project is to integrate the phasor measurement system with the existing EMS and an updated Visualization subsystem to include phasor functions analysis and other data streams Each of the subsystems is functionally defined in the following The existing EMS will be expanded to use phasor measurements for all applications especially State Estimation NEW YORK INDEPENDENT SYSTEM OPERATOR SUBSTATION PMU Iso SUB s PDC DFR Others DR es SUB PDC PMU NYISO NY TOs Figure 1 SGI Overview The integration of the PMN with the other subsystems will be labeled as the SGI system The system configuration shown is one depiction of an integrated composite system Vendors are encouraged to propose alternative designs to demonstrate the capabilities of their components additional system flexibility of their subsystems and scalability for extended future growth capability The composite system is expected to include several application functions at the uppermost PMN level Several designs label this level as a Super PDC Master PDC or Control Center PDC This representation uses the term Phasor Data Acquisition and Control PDAC as there are multiple applications that are expect
16. started automatically upon SGI receiving one or more of the following 13 Breaker switching operations notification Yes No 14 Relay operations indication Yes No 15 DFR new record notification Yes No 16 SGI shall also be able to invoke the fault location function manually for calculating a line s fault location In this case users shall be able to select a line and select the fault location calculation method to be used to start the fault location calculation Yes No C 5 Post Event Analysis Post event analysis should have the ability to demonstrate power system replay for post event analysis Additionally it should efficiently handle PMU data related to an event The PEA application should be functionally designed to accommodate at a minimum the following 1 Retrieve archived records Yes No 2 Tolerate data being delivered to archives up to one hour late Yes No 3 Ability to recover protocols that move data to archive after connectivity failures Yes No 4 Keeping data on demand for a specified period week month or year Yes No 5 Ability to reverse video or highlight important data lines Yes No 6 Be accurate enough to buffer all levels of architecture Yes No 51 NEW YORK INDEPENDENT SYSTEM OPERATOR C 7 7 Ability to handle chain of custody Yes No PMU configuration data availability along with the data rate Yes No Event analysis should be time synchronized with
17. to retrieval missing data from substation PDCs or other PDCs that have their own data storage capability 62 Does the product provide a late data handling function If yes please describe how late arrival data is handled e g discarded or stored with an arrival time tag etc B 3 8 System Management Capabilities 63 Does the product provide system management functions for device management applications management and so on 64 Does the product manage the device and applications registration and configuration If yes please describe how these are managed 65 Does the product keep logs on the device and applications registration and configuration changes 66 Does the product system management function manage the start and stop of applications 67 Does the product include system resource management functions 68 Does the product provide security services for system access control 69 Does the product provide system status monitoring mitigation and alarming functions B 3 9 Applications Included 70 Does the product include any supporting system applications such as data visualization simple manipulation of stored data etc If yes please describe each of them To be completed 71 Does the product include any alarm functions If yes describe what types of alarm functions are included how each function works and the purpose of each alarm function 72 Does the product include any substation monitoring protec
18. within 5 seconds after the fault occurrence Yes No The function shall be able to perform the fault location calculation or estimation on each identified faulted line where fault recordings from at least one end of the line are available Yes No The function shall provide multiple fault location calculation and estimation methods for users to select Yes No The function shall support fault location calculation or estimation using either synchronized or non synchronized fault records Yes No The function shall support fault location calculation or estimation using either single end method or multi end method Yes No 50 NEW YORK INDEPENDENT SYSTEM OPERATOR 10 The function shall be capable of indicating the type of fault such as symmetrical or non symmetrical phase s involved in the fault and the estimated fault resistance for ground faults Yes No C 4 3 Fault Location User Interface The fault location function user interface shall provide all the flexibility to set up parameters for both manual and automated fault location calculation while minimizing the amount of manual entry To perform fault location while minimize the amount of manual entry the fault location function user interface shall support the following 11 Making use of or re define default values Yes No 12 Setting up automatic execution of fault location function Yes No C 4 4 Execution Procedures Fault location function shall always be
19. witness points during the manufacture assembly and testing activities for the equipment including subcontracted components Yes No Does the supplier have testing procedure to ensure all anticipated vulnerabilities are addressed and no new vulnerabilities have been introduced Will the supplier agree to a consultant to witness the factory site acceptance tests review simulation tests and results The Testing should include at minimum the following a Standards compliance Yes No b Design verification simulation Yes No c Functional test plan Yes No d Integration interface with existing equipment Yes No e Protocol compliance Yes No f Environmental i Electrical Yes No 1 Transients Yes No 2 Insulation Yes No 3 EMI RFI Yes No ii Mechanical 1 Vibration Yes No 59 NEW YORK INDEPENDENT SYSTEM OPERATOR j 2 Temperature Yes No 3 Humidity Yes No Cyber security Yes No Interoperability with other equipment Yes No Device performance validation Yes No System performance validation Yes No 8 Tests procedures should include a b Inspection or test objectives Yes No List of components to be inspected or tested referring to specification item standards used ANSI ASTM etc Yes No Criteria for inspection or test acceptance and rejection Yes No Test configuration Yes No Test prerequisites Yes No Description of testing facility Yes No Auth
20. EM OPERATOR 10 Is the high speed secure network in compliance with NERC CYBER SECURITY requirements Yes No Is the hardware and software open to future system expansion upgrade application addition performance and security improvement Yes No Can the vendor system support current DFR PMUs placement and PMU replacement plan for up to XX kV and kV substations plus external synchrophasor data exchange with other entities for up to XX similar substations Yes No Does the vendor provide reliable data acquisition and archiving for off line engineering applications such as a Post disturbance analysis such as NYISO s Power System Analysis PSA or other similar ones with at minimum PSA s current functionalities trending for active and reactive power magnitude and phase angle of V and I phasor measurement phasor vector diagram display low frequency oscillation analysis etc Yes No b Play back and forward simulation Yes No c Modal or oscillatory analysis Yes No d System model validation Yes No Does the vendor have a reliable data acquisition and buffering capability for real time situation awareness applications meeting the overall speed requirement preliminarily set at the one second latency maximum Yes No Can the three basic functionalities for all real time situation awareness applications be provided a Alarm and warning Yes No b Trending Yes No c Compliance logging and reporti
21. Model 56 Appendix D Capacitor E EE 57 Appendix E Cyber aerie eeue ese oi E EE EEEE ge gie 58 Appendix EK 59 Supplemental A Communication Protocols ccssccsssscssccssscssesessccsecsssscsssnssssccsensesacesnaseees 61 To be completed when additional information is provided by NNISO ee ees see ee ee 61 Communication Requirements General 61 e Products can communicate over Generic Object Oriented Substation GOOSE OM SSN EE 61 e Products can communicate over OPC eso 61 e Products can communicate over ModBus eso 61 e Products can communicate over Distributed Network Protocol DNP Yes No 61 e Products can communicate over Inter Control Center Protocol ICCP Yes No 61 Supplemental C Glossa EE 62 NEW YORK INDEPENDENT SYSTEM OPERATOR 1 0 Introduction 1 1 Purpose The New York Independent System Operator NYISO and New York Transmission Owners TOs are deploying a Phasor Measurement Network PMN capable of achieving complete situational awareness of the New York bulk electric system BES and Smart Grid enabled capacitors the Project The PMN will be integrated with a visualization subsystem an energy management system EMS historical information subsystem and other PMNs This request for information RFI is to assist in the development of the technical and functional requirements for the PMN The technical requirements will encompass intelligent electronic devic
22. OR Zonal voltage patterns at key facilities Yes No 105 Relative angle trends at key facilities Yes No B 4 5 Visualization Management Services VMS Visualization management services will support a full graphical operational visualization environment for centralized and systematic real time wide area system monitoring and information presentation and multi layer display of synchrophasor data from applications and data management subsystems The vendor should confirm if the visualization subsystem satisfies the minimum requirements listed below 106 Multi view graphical information display Yes No 107 One main view for system wide information visualization and presentation Yes No 108 Multiple sub views for both system wide and detailed information visualization and presentation Yes No 109 Multi layer information visualization and presentation capability with role based authentication and authorization Yes No 110 Main view shall have a geographic layer as its base layer to allow the integrated information visualization and presentation of PMU _ data alarms calculations with imported SCADA EMS real time fire traffic weather earthquake lightning indicator data and system one line diagrams in other overlay layers Yes No 111 Ability to bring in and display information from any real time application Oe FNET Yes No 112 Dynamic updates with status changes such as dynamic line coloring islanding etc Yes No
23. Oscillation Monitoring LFOM Each system has some natural oscillation frequencies When the system is excited with a disturbance such as a fault it works as an impulse to the system and the oscillating modes reflect in the measured quantities Depending on the observability of the modes of oscillation in the measurement the modes can be detected by spectral analysis or other means The corresponding frequency and damping of each mode can be calculated using different algorithms If the damping ratio is lower than 5 it is considered a poorly damped system where the oscillation may continue for a prolonged duration causing other undesirable events to happen The low NEW YORK INDEPENDENT SYSTEM OPERATOR frequency oscillation monitoring application should provide the information in real time so that corrective actions can be taken The low frequency oscillation detection application normally identifies the low frequency oscillation present in an event if it falls under the range of interest typically the low frequency range should be user selectable and lies within 0 1 Hz to 2 Hz This helps to identify the critical poorly damped modes so that the operator can make decisions on re dispatch or some other means to alleviate the small signal stability problem 3 44 Fault Location FL A fault is an abnormal condition in a power system Fast fault detection and isolation by protective relays are critical to the overall power system health Howeve
24. Project track system design studies will be conducted to optimally site sources of PMU information within the PMN determine communication requirements and develop system planning and operations protocols to leverage data from the PMUs Vendors will deploy a suite of wide area situational awareness software at the NYISO s control centers to serve as the platform for the PMN The third Project track involves the integration of new reactive power sources through the installation of additional shunt capacitors by Central Hudson Gas and Electric Corporation Consolidated Edison Company of New York Inc Niagara Mohawk Power Corporation d b a National Grid New York State Electric and Gas Corporation and Rochester Gas and Electric Corporation within their respective transmission districts These smart grid enabled devices will enhance the control and coordination of the voltage profile on the New York power grid resulting in improvements to the efficiency and reliability of the New York power grid These switched controllable capacitor banks will provide additional reactive power resources to the bulk power system during system conditions where and when it is needed the most The TOs NEW YORK INDEPENDENT SYSTEM OPERATOR may engage multiple vendors to purchase install and integrate the capacitor banks with their respective SGI The Project will provide for enhanced functionality through the deployment of smart grid technologies throughout New
25. Reactive Power Plot Yes No 42 NEW YORK INDEPENDENT SYSTEM OPERATOR h Af At Plot Yes No i Phase Angle Plot Yes No 125 Path Flows for selected flowgate or corridors Yes No 126 Graphs must have an option to use actual value or deviation from nominal value Yes No 127 Ability to freeze a graph for taking a snapshot Yes No 128 Ability to close and clear a graph Yes No 129 Ability to cascade selected graphs Yes No 130 Support for authoring tools Yes No B 4 6 Historian Data Server HDS The vendor system should confirm the minimum requirements set forth in this section 131 There must be a high availability historian for archiving historical synchrophasor and related data to support SGI operations and applications Yes No 132 The data retention for this historian is X year Yes No 133 Fault tolerance can be provided in various ways but must be compatible with the inter site failover architecture Yes No 134 There is also a requirement for long term X year storage for the corporate users Yes No 135 Ability to provide services to SGI users and a number of non SGI users while ensuring that the security and performance of the other component systems of the SGI are not impacted Yes No B 4 7 Real Time Data Server RTDS The vendor system should confirm the capabilities set forth in this section 136 There must be a high availability historian within the Information St
26. STEM OPERATOR 67 Does the device provide a minimum of 10 minutes power failure bridging time with an internal battery Does the device allow users to fully comply with NERC CIP requirements when connected to the PMU system network For integrated PMUs 69 70 71 72 73 74 75 76 B 3 B 3 1 Does PMU function share the same input circuits and analog filters with other functions Does PMU function share the same binary input output connectors with other functions Does the PMU function share the same Ethernet communication ports with other functions Can PMU function and other functions be configured independently Can the PMU function be configured without stopping the operation of other functions Can other functions be configured without stopping PMU function Can the device be configured as a standalone PMU device Has the device been tested to confirm that normal PMU function will not be affected under the peak operation of other functions If yes please provide a detailed description about how the device was configured how the test was performed and the recorded results Phasor Data Concentrator PDC Function PDC Specific Questions 1 Off the shelf Control Center PDC product offerings please list all models that have been released to the market 2 Planned Control Center PDC product offerings please list all models that planned to be released to the market within one year 3 S
27. Us connected to each EPDC the number of measurement points of each PMU and or the measurement data that NYISO has agreement with Data volume estimation could be based on NYISO s DFR PMU with the maximum measurement configuration for each unit All ISO member utilities should be assumed to have one EPDC each 150 EPDCs shall provide the configuration information of the streamed data to PDAC upon PDAC s request Yes No 151 The request and sending configuration information shall conform to IEEE C37 118 2005 format Yes No EPDC Output 152 PDAC shall provide data streams to EPDCs that NYISO has agreement with PDAC will send one data stream to each EPDC in IEEE C37 118 2005 format Yes No 153 PDAC shall provide data stream configuration information to an EPDC upon receiving the reguest from the EPDC The reguest and sending configuration information shall conform to IEEE C37 1 18 2005 format Yes No 45 NEW YORK INDEPENDENT SYSTEM OPERATOR Appendix C Applications C 1 Voltage Phase Angle Monitoring VPAM A dedicated application will be specified to observe the phase angle differences between any two buses in the system where PMUs are installed The VPAM application capabilities should be functionally defined by the following l The application should be capable of handling the digital phasor data from PDC or real time storage in floating point format Yes No The application should be able to e
28. Yes No The PDAC shall have modular characteristics performance processing power and or network interfaces to allow for accommodating system expansion in the numbers of PMUs and DERS installed Yes No SGI shall be able to guarantee the Quality of Service QoS for SGI applications initially deployed and shall be able to expand and upgrade to guarantee the QoS for future SGI applications Yes No SGI shall be expandable to meet NERC s CYBER SECURITY compliance requirements Yes No SGI shall be capable of distinguishing labeling and segmenting data from external non NYISO sources Yes No SGI shall be capable of operating with no external data continuing to perform all major functions not fundamentally based on said data Yes No 14 NEW YORK INDEPENDENT SYSTEM OPERATOR 10 SGI shall be capable of distinguishing labeling and segmenting specific types or classes of external data e g weather vs NASPInet Yes No 11 SGI shall be an open system supporting system interoperability standards to the extent required and possible Yes No 12 SGI shall include adequate data storage capacities at different levels or components of the system to prevent data loss and ensure adequate historical data availability for planning and engineering as well as operation analysis The data storage shall include the following a Data stored at the device and component level e g PMU DFR PDC for internal component function
29. York State in the electric transmission system topic area as follows e This Project consists of the deployment of an NYCA wide open flexible interoperable secure and expandable PMN system that will be integrated with existing monitoring and potentially control systems The PMN system will operate using standard information models and communication protocols and will be an integral part of an interconnection wide synchrophasor network The New York TOs will strategically install synchronized PMUs with optional substation PDCs and PDCs at their respective control centers The TOs will also provision the necessary communication and networking equipment and facilities to transmit synchrophasor data to PDCs installed by the NYISO at their control centers e The NYISO will deploy synchrophasor measurement based functions such as monitoring of small signal oscillations damping voltage stability and angular separation voltage current frequency and phase angle as well as other functions including enhanced state estimation system model calibration and a study to analyze opportunities for controlled system separation e The TOs will integrate new reactive power sources through the installation of additional Smart Grid enabled shunt capacitors These switched controllable capacitor banks will provide for additional reactive power resources that will improve power delivery system efficiency through improved voltage profiles and the reduction
30. ailable 20 A summary description of the product 21 Product specification 22 User manual 23 Initial release date of the product 24 Number of units sold 25 Type certification test reports 26 Lead time for ordering 27 Spare parts and replacement support 28 Warranty period For each PMU product please answer the following specific questions provide additional details to each answer For both standalone PMUs and integrated PMU Relay PMU DFR PMU etc 29 Is the device capable of measuring positive sequence phasors from three phase inputs 24 NEW YORK INDEPENDENT SYSTEM OPERATOR 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 0 Is the device capable of producing positive sequence phasors from single phase input Is the device capable of measuring single phase phasors for each phase of three phase inputs Does the device provide internal compensations for VT PT errors Does the device provide internal compensation for CT errors Does phasor measurement support all reporting rates of C37 118 2005 Does phasor measurement support reporting rate of 60 frames s Does phasor measurement support reporting rate of 120 frames s Does phasor measurement performance at 10 12 15 20 and 30 frames s meet level 1 requirements of C37 118 2005 Does phasor measurement performance at 10 12 15 20 30 and 60 frames s meet class P and M requi
31. al disturbances in phasor format and provide continuously streamed phasor measurement data to phasor data concentrators at GCC or other locations Yes No Through the use of a GPS clock the PMU function must be able to generate phasor measurement data synchronized with UTC from installed locations throughout the power system Yes No A PMU whether it is a standalone or an integrated unit typically must have a number of analog and digital channels The number of available analog and digital channels can vary Analog channels can be utilized to record real time information and can be configured as either a voltage phasor or a current phasor Vendors are required to specify how many analog and digital channels the PMU will support Yes No Synchrophasor data should be continuously streamed from the PMUs to the PDAC at a typical rate of 30 60 frames per second The streamed synchrophasor data will be pushed to PDAC and SDM for validation and will be stored in Real Time and Historian SGI databases Yes No The information captured by the NYISO DFR PMUs store rows of positive sequence phasor data As a real time phasor measurement instrument some PMUs may be expected to both transmit and or receive phasor data to from remote locations Yes No The PM function must be able to compute the positive sequence voltage and current phasors at precisely the moment synchronized with UTC Yes No The computed data can be transmitted on a very high s
32. ales and technical support info 4 Field implementation support 5 Response time to product problems 6 For each Control Center PDC product model please provide the following specific information materials if available 27 NEW YORK INDEPENDENT SYSTEM OPERATOR 7 A summary description of the product 10 11 12 13 14 15 Product specification User manual Initial release date of the product Number of units sold Type certification test reports Lead time for ordering Spare parts and replacement support Warranty period For each Control Center PDC product please answer the following specific questions Provide additional details to each answer as needed for your offering to be understood B 3 2 Type of Control Center PDC 16 E 18 19 20 21 22 Is this a phasor data concentration only product meaning that it only handles phasor measurement data from various PMUs PDCs substation PDCs other control center PDCs etc Is this a general data concentration type of product meaning it may also handle different types of data other than the phasor measurement data from various PMUs in a substation PDCs The other types of data could include such data as DFR data relay data remote terminal unit data and so on Is this an all inclusive WAMS or WAMPAC system offering that includes the phasor data concentration data management system management WAM WAC WAP applications visualiza
33. an database COMTRADR format Yes No Stores PMUs synchrophasor data in SGI RT database IEEE C37 118 format Yes No Stores external Proxy data earthquake fire traffic and weather Yes No Delivers data requested by Applications application defined API format Yes No Delivers data requested by Visualization IEEE C37 118 format Yes No DFR data recording trigger Yes No Initiates DFRs area or global recording requests requested by application Yes No EMS Interface via GCC EMS and SGI LAN Yes No Maps PMU measurements to the SCADA points and network model devices gens loads branches etc Yes No Puts PMU measurements in SCADA database for State Estimator SE use at a sample rate of one sample per second Yes No Retrieves SE solution from EMS application database server every minute to update visualization displays Yes No Retrieves SCADA values from SCADA database server for visualization displays Yes No Validating PMU measurements vs SCADA values when available Yes No Transferring requested PMU and DFR data to engineering database by request IEEE C37 118 and COMTRADE format Yes No Application Management Services AMS The main task of Application Management Services is to run SGI analytical engineering and other applications The added PMN applications are expected to be integrated with the existing 38 NEW YORK INDEPENDENT SYSTEM OPERATOR EMS application management services function Fol
34. asor Data Concentrator CCPDC installed in the control center The CCPDC would then dispense the data to various applications including visualizations historians and control and protection applications The system would also incorporate a fast reliable and secure communication network for data transfer and for control actions commands to flow to the various controlled equipment The applications also include post mortem analysis tools to allow the system operator to reproduce replay the archived data records and be able to perform a cause effect analysis The system must also allow reasonable system expansion for the foreseeable future to allow for equipment upgrades modernization and other system enhancements 2 3 SGI System Requirements for Future Expansion Integration The system is to be expandable to perform all future functions as listed with PMU data gathered from the expansion list The system should be open to migration to an alternative energy management system when it is decided to retire the existing EMS 2 4 PME Field Devices This section focuses on the functionality and data flow requirements of each SGI component in the Field Devices subsystem The system will consist of several field devices including Phasor Measurement Equipment and Phasor Data Concentrators The following minimum requirements are required from Vendor s systems 2 4 1 PME Function Phasor Measurement Equipment may be any device that is capable of
35. ce telecommunications networks with virtual links between distant nodes and ability to encapsulate packets of various network protocols MS Master station NASPI North American Synchrophasor Initiative NASPInet NASPI network a high speed high availability and highly secure data communication network and IT infrastructure to enable synchrophasor data sharing across North America NERC North American Electric Reliability Corporation NYCA New York Control Area NYISO New York Independent System Operator NYPA New York Power Authority PDAC Phasor Data Acquisition and Control PDC Phasor Data Concentrator PDAC Phasor Data Acquisition and Control Subsystem PEA Post Event Analysis PME Phasor Measurement Equipment PMN Phasor Measurement Network PMU Phasor Measurement Unit PSA Power system analysis QoS Quality of service RAS Remedial action scheme RFI Request for Information RFP Request for Proposals RT Real time RTDS Real time data server SCADA Supervisory control and data acquisition SDM System and data management SE State estimator an EMS application to estimate states of the power grid based on points where measurements are available SEIM Security Event Incident Management SGI Smart Grid Infrastructure 63 NEW YORK INDEPENDENT SYSTEM OPERATOR Acronym Description SMART Synchronized measurement and analysis in real time SMU Synchronized Measurem
36. conds and highly reliable no interruption under any signal point failure messaging and intra inter data exchange for protection and control applications Yes No 19 NEW YORK INDEPENDENT SYSTEM OPERATOR Appendix B Equipment 1 B 1 General info about your company s PMU product offerings off the shelf products and ones under development supplying info lead time etc Specific info for each PMU product that your company offers type of the device standards supported standards compliance HW SW functions and capabilities device specifications etc General info about your company s substation PDC product offerings off the shelf products and ones under development supplying info lead time etc Specific info for each substation PDC product that your company offers type of the device standards supported standards compliance HW SW capabilities device specifications etc General info about your company s control center PDC product offerings off the shelf products and ones under development supplying info e g lead time etc Specific info for each control center PDC product that your company offers type of the device standards supported standards compliance HW SW capabilities device specifications etc Digital Fault Recorder DFR Function The DFR function is one of the two main functions of the combined DFR PMU devices NYISO plans to install Vendor s response should state whe
37. e expected to be issued in either the fourth quarter of 2010 or the first quarter of 2011 The RFI is composed of two items The first item is this document that describes the overall project the expected architecture and the functions that are required currently or expected within the lifetime of the project equipment The second item is a spreadsheet The associated spreadsheet should be used for providing the requested information listed in the appendices The spreadsheet will be used to quickly understand the capabilities and the quality of each vendor This project is to consist of equipment and systems that are ready for deployment NEW YORK INDEPENDENT SYSTEM OPERATOR 2 0 System Requirements 2 1 PMN System Requirements Summary The PMN will include the field devices to sensor and to compute the phasor values at a rate to be defined The system is expected to function over a ten 10 year period as the number of phasor measurements increase each year The equipment to sensor and convert the data is not to be based on any one manufacturer but will be based on various manufacturers as awarded by the NYISO and the various Transmission Organizations 2 2 SGI System Requirements for Current Deployment The general synchrophasor system installation for a utility would consist of several Phasor Measurement Equipment PME devices installed in substations a Phasor Data Concentrator device installed in each substation and a Control Center Ph
38. ed to reside at this level It is thus expected that a platform far in excess of a data concentrator would be needed to support these functions The functions planned as part of this procurement are listed as well as functions that may be included in the future Vendors should provide information on the capability of their products to provide such functional support or an alternative architecture to provide the same functional capability The visualization subsystem is to provide a complete situational awareness view to BES operators beyond the traditional EMS one line and tabular displays The visualization system is described in the following and may or may not be a part of the existing EMS system The visualization system is to enable integration of the traditional EMS displays with phasor data and with calculations based on phasor data to provide additional operational information NEW YORK INDEPENDENT SYSTEM OPERATOR The composite system is expected to be interconnected with other energy control centers and PMNs Vendors should provide information on the limitations of such interconnection the level at which such interconnections are supported the capabilities of existing or planned equipment and how such interconnections may be expanded The NYISO expects to integrate this system with the systems at each Transmission Owner and at each adjacent Independent System Operator It is expected that PMUs and PDCs at the generation sites will ev
39. ements Yes No Can the DFR PMU Units communicate with the PDAC or Data Management Subsystem via both UDP IP and TCP IP protocols through an IP based network both IPv4 and IPv6 shall be supported Yes No The destination IP address of DFR PMU when using UDP IP protocol shall be user configurable and shall include multicast address space Yes No PDAC shall be able to support multiple data and messaging protocols such as IEEE C37 118 2005 data frame protocol ICCP IEC 61850 UCA GOOSE messaging standards DNP 3 0 and OPC Yes No Can the system recover lost data if errors occur in telecommunication channels this could be achieved in part by pushing the data to both primary and backup PDACs but primarily through DFR PMU local data storage and lost data retrieval through PDAC 2 PDC or DFR PMU interactions Yes No Is the received data in the PDAC available for analysis by computer programs executed on the PDAC Application Server and also accessible through NYISO internal network for remote analysis Yes No Does the system ensure data filing backup and restoration after hardware or software failure Yes No What is the maximum Phasor data latency for Visualization 17 NEW YORK INDEPENDENT SYSTEM OPERATOR Can the system handle a minimum of 30 days online full data storage for all received Dee data at PDAC and other data at CCS Yes No 23 Can the vendor s system provide a minimum of five 5 year s even
40. ems An important function of the SM is to provide system administration functions such as PDAC PDC DFR PMU registration external PDC registration application registration and so on This will allow SGI to provide system configuration services and security services The minimum input output and service requirements must be provided SM Input 18 PDC configuration Yes No 19 DFR PMUs configuration Yes No 20 Applications data output TBD Yes No 21 External data Proxy servers Yes No 22 Real Time Data needed by application Yes No 23 Grid network data from EMS server Yes No 24 EMS PDAC Historian output Yes No SM Output 25 Validated and quality checked PDC DFR PMU configuration Yes No 26 Validated and quality checked external proxy configuration Yes No 27 Pass through EMS data Yes No 28 Pass through application outputs Yes No SM Services Data Base Delivery via GCC SGI LAN 29 Delivers data requested by Applications Yes No 36 NEW YORK INDEPENDENT SYSTEM OPERATOR 0 Delivers data requested by Visualization IEEE C37 118 format Yes No 31 DFR data recording triggers Yes No 32 SCADA EMS Interface via GCC SCADA EMS and SGI LAN Yes No 33 Maps PMU measurements to the SCADA points and network model devices gens loads branches etc Yes No 34 Map of PMU measurements in SCADA database for State Estimator SE use at a sample rate of one sample per second Yes No B 4 3 Data Managemen
41. ent Unit SOA Service Oriented Architecture TO Transmission Owner SOAP Simple Object Access Protocol SPDC Super Phasor Data Concentrators TCP Transport control protocol UDP User datagram protocol a simple protocol used in the Internet a core member of the Internet Protocol IP suite unlike TCP UDP is compatible with packet broadcast sending to all on local network and multicasting send to all subscribers VPAM Voltage Phase Angle Monitoring VS Visualization server VSM Voltage stability monitoring WAC Wide area control WAM Wide area monitoring measurement WAMPACS Wide area monitoring protection and control system WAP Wide area protection WDSL Web services description language WED Wide Area Event Detection 64
42. entually be added This SGI system shall support the scope of deployment proposed through this Project and the future expansion evolvement and integration as part of an overall Smart Grid rollout effort Therefore this system must e Deliver the initial functionality described in this document e Be flexible enough to scale to support the data growth described above and e Remain consistent with the present industry architectural vision of the Smart Grid Although some components in the overall description may not be included in the initial deployment the architecture shall take the future integration and migration to this overall Smart Grid system architecture into consideration 14 2 Smart Grid Enabled Capacitor System Components The TOs will integrate new reactive power sources into the NYCA through the installation of additional Smart Grid enabled shunt capacitors These switched controllable capacitor banks will be installed on the distribution and transmission systems and will provide for additional reactive power resources that will improve power delivery system efficiency through improved voltage profiles and the reduction of system losses 1 5 Structure of this Request for Information This request for information RFI is to provide the basis for the request s for proposal s RFP that will be used to procure the PMN software applications associated integration services and Smart Grid enabled capacitor systems The RFP s ar
43. epts or to the individual questions that follow The respondent is to answer questions that reflect their expertise and experience for equipment and components Respondents are not required to nor necessarily expected to answer all questions if such questions are inappropriate to their offerings A yes no or numeric answer is expected If additional information is provided then the column adjacent should list the linked document A A 2 General Provide a general description of your company What types of equipment could your company supply for PMN project List each type of equipment in the following category PMU PDC applications capacitor system integrators etc Will you possibly subcontract to another vendor or contract other vendors as a subcontractor Any additional info about your company relevant to this RFI PMN System Requirements Summary Is your system scalable to support future system expansion this includes both hardware and software applications with capability to scale up to accommodate the rapid increase of substations with new measurement sources anticipated in next ten years and beyond Is your equipment and system adaptable to interoperability and cyber security standard evolvement over the life span of the system Is your system capable of providing support for regional i e NPCC NERC NYSRC and EI functions e g post mortem fault analysis Can your system handle data sharing with o
44. equirements for Future Expansion IntegratHON ees esse see se ee se ee ee ee 19 Appendix DBE RE AR EA GE N GREG GR Ge NG GE ES ee 20 BA Digital Fault Recorder DER Function sesse esse gesek ees ed sesse ne we es le Des sok ee ooN Ve 20 Bi Phasor Measurement Unit PMU Functnon 22 B 3 Phasor Data Concentrator CEDIES 27 BA PMN Data Processing Data Management and Applcatons sees sees ses see ee ee ee 34 Appendix Ap CANONS E 46 C 1 Voltage Phase Angle Monitoring VPAM ees ese ese ee ee ee ee Re ee ee RA ee Re ee ee ee ee ee 46 C 2 Voltage Stability Monitoring NM 47 C 3 Low Frequency Oscillation Monitoring FOM ees esse ee see ee ee ee RA ee Re ee ee ee ee ee 48 C4 att Leer RE EE a ATEENA SEENEN RE EO EEEE ERTSE 50 CALL Faulted ER ee EE 50 C42 Faul Location eelerer 50 C43 Fault Location E 51 CAA Execution reegt deene EE 51 ES WE GENEE 51 G DER Records Retrieval esse iese she eg ese ee Re Ge Ge ke be ee Ge eg be 52 C 7 Global DER Event Trigger Manage sedaedeee esse iese Eegen ese INN es N SR Ee 52 NEW YORK INDEPENDENT SYSTEM OPERATOR CH Wide Area Event Detection WED cccccccccesseceessecesseceessecesseeceeeeeeceeseceeeecseeeesnes 53 C 9 Wide Area Situational Awareness js iiss cisssdeesdesccasesapesesaansdedeiancoaevss ENEE Egeter 53 C10 Voltage Stability EE 54 C 11 Site Estimation EMS EE 55 C 12 Calibration and Validation of NYISO s System Model 55 C 13 Calibrate and Validate of NYISO s Dynamic System
45. es IEDs capable of performing synchronized phasor measurements including phasor measurement units PMUs phasor data concentrators PDCs super phasor data concentrators SPDCs EMS enhancements communications and associated applications The technical and functional requirements developed from the information obtained through this RFI will be used to procure the PMN equipment components applications and integration services through competitive solicitation facilitated through one or more Requests for Proposals RFPs This Project is partially funded by the Department of Energy Smart Grid Investment Grant an American Recovery and Reinvestment Act ARRA funded program 12 About the NYISO The NYISO is at the heart of New York State s electric system operating the high voltage transmission network administering and monitoring New York s wholesale electricity markets and planning for the State s energy future The TOs are comprised of the following entities i Central Hudson Gas amp Electric Corporation 11 Consolidated Edison Company of New York Inc iii New York State Electric amp Gas Corporation iv Niagara Mohawk Power Corporation d b a National Grid v Orange and Rockland Utilities Inc vi Rochester Gas and Electric Corporation NEW YORK INDEPENDENT SYSTEM OPERATOR vii the Power Authority of the State of New York a corporate municipal instrumentality of the State of New York NYPA
46. high sample rate data Yes No DFR Records Retrieval DFR records retrieval system should have the capability to provide both continuous and long term recording Yes No Continuous recording should have the ability to retrieve information up to 100 days that comply with NERC standards a PRC 002 1 Define Regional Disturbance Monitoring and Reporting Requirements Yes No b PRC 018 1 Disturbance Monitoring Equipment Installation and Data Reporting Yes No Long term recording should have logs of signals power and frequency Programmable record length should be at least 90 days Yes No For high speed fault recording the following specifications are required a Pre fault Period up to 10 seconds with a default setting of 10 cycles Yes No b Post fault Period maximum post fault continuous data streaming needs to be provided Yes No DFRs should have the capability to record data simultaneously in three domains a High Speed Transient Fault that can record more 350 samples cycle Yes No b Low Speed Dynamic Swings that can record up to 30 minutes Yes No c Continuous Trend from 10 seconds to an hour Yes No The DFR records retrieval system should be designed with a recorder analog input isolation modules and GUI software The system should additionally be capable of feeding into Disturbance Monitoring Equipment DME with the ability to capture record disturbance data per NERC Standard PRC 018 Yes N
47. identifying the critical poorly damped modes such that the operator can make decisions on re dispatch or some other means to alleviate the small signal stability problem The LFOM application should be functionally defined by the following l The application should have provisions to identify the modal content of measured signals such as voltage magnitude phasor current magnitude phasor or phase angle differences Yes No Modal content comprised of frequency of oscillation of critical modes less than certain frequency to be specified by NYISO corresponding damping of such modes and amplitude of such oscillations Yes No Provisions should be in the application to identify a growing oscillation and generate warning and alert messages Yes No 48 NEW YORK INDEPENDENT SYSTEM OPERATOR The modal identification is to be performed either at each sampling time or at every N sampling as specified by NYISO Options are to be provided in the application to select refresh rate of such calculations by the operator Yes No What is the required calculation time for this application The application should be able to send data streams to other visualization applications in a standard format The data stream should contain frequency damping and oscillation amplitude information of each oscillating mode observed in the PMU data the time stamp information and any warning or alert messages Yes No The application should also c
48. ion rate at 30 or 60 samples per second Yes No 14 Estimation of bandwidth requirement for an assumed DFR PMU 18 bytes HDR SOC FRACSEC PMU_ID CRC Yes No z 8 bytes overhead Yes No c 8 bytes STAT Yes No d 80 bytes phasors PMU with 10 phasors Yes No e 4 bytes FREQ DFDQ Yes No f 4 bytes DIG Yes No g 122 bytes Message total Yes No h 122 bytes msg X 30 msg sec 3660 bytes sec Yes No i 3660 bytes sec X 8 bits byte 29 280 bits sec bps actual data rate Yes No Needs recalculation per NYISO input j Provision should be made for each PMU having 23 NEW YORK INDEPENDENT SYSTEM OPERATOR 1 amaximum of 20 phasor outputs at 60 samples per second Yes No 2 amaximum of 30 to 40 digital outputs at 60 samples per second Yes No k Communication provision at each substation shall also consider the total number of DFR PMU installed in the substation if these DFR PMUs will share the same communication path B 2 2 PMU Specific Questions 15 Off the shelf PMU product offerings please list all models that have been released to the market 16 Planned PMU product offerings please list all models that planned to be released to the market within the life of the project equipment 17 Sales and technical support info 18 Field implementation support 19 Response time to product problems For each PMU product model please provide the following specific information materials if av
49. ions The system should be able to enable more advanced applications to assist Real Time Wide Area Operation Control and Protection in the future 4 0 SGI Cyber Security Requirements The SGI should comply with all applicable NERC and NIST cyber security requirements The NYISO conducts a Vendor Assessment to assist in determining such compliance All Vendors are required to complete the NYISO s Vendor Assessment Questionnaire provided hereto in Appendix E which will be used in the assessment of all Vendors 5 0 RFI Response Instructions 5 1 Correspondence Please direct all questions correspondence and responses related to this RFI to mrubin nyiso com with NYISO SGI RFT included in the subject line 52 RFI Schedule The schedule for this RFI is gt Release RFI Wednesday July 21 2010 gt RFI Responses Due Friday August 20 2010 3 00 PM EDT 11 NEW YORK INDEPENDENT SYSTEM OPERATOR RFI Response Format 5 3 1 Cover Letter The cover letter shall be in the form of a standard business letter and shall be signed by company interested to supply equipment to NYISO SGI project 5 3 2 Responses to Questions The answers to the Questions should be provided as a digital attachment to the cover letter using the applied spreadsheet 5 3 3 Response Format The cover letter and other supplemental attachments should be provided in either MS Word versions 2007 or 97 2003 or Adobe Acrobat format 5 4 Documen
50. ld detect events based on PMU measurements using currently available data Yes No 3 Other important wide area event detection should include a Comprehensive of voltage angles and magnitudes Yes No b Monitor angles relative to a specific reference Yes No 4 Identifying Over and Under voltage regions within a specific area Yes No C 9 Wide Area Situational Awareness 1 Is there a situational awareness application provided with the software 2 How many PMU and DFR devices can be accommodated in your WASA application 3 How much disk space the module needs 53 NEW YORK INDEPENDENT SYSTEM OPERATOR 4 5 6 10 11 12 13 C 10 How much computer processing time is needed to process each PMU data Is a network model needed for the WASA application Does the WASA application provide functionalities of a Real time grid view with geographical locations b Voltage current power and other relevant measurements at each critical locations c Monitor phase angle differences at different critical regions d Assessment of voltage stability e Detection of System oscillations frequency of oscillation damping f Fault location detection Does the WASA application provide multi view of grid conditions with topological diagram Does the application need any data from other applications What communication protocol is used to exchange data between applications What is the cost of the WASA application
51. lowing is a summary of application server functions AMS Input 64 Validated streaming PMU EPDC data Yes No 65 Validated PMU EPDC data from SGI Real Time database Yes No 66 PDAC streamed PMU data not validated by SDM Yes No 67 DFRs data from SGI Real Time database Yes No 68 Grid digital and analog data from EMS database Yes No 69 Grid network solution data from SGI Real Time database Yes No 70 External non electrical data from SGI Real Time database Yes No 71 Application output data from SGI Real Time database Yes No AMS Output 72 Alarms and violations to be reflected in visualization Yes No 73 MW and MW flows and losses Yes No 74 Compliance Reports Yes No 75 Performance Reports Yes No AMS Services 76 MW and Mvar flow calculations Yes No 77 MW and Mvar loss calculation Yes No 78 Line thermal monitoring Yes No 79 PMU measurement versus SCADA data validation Yes No Generating multi level category Alarms amp Warnings based on 80 Monitored Voltage Phase Angle differences between two points and or any points to the reference point Yes No 81 Low voltage detection Yes No 82 Measurements rate of change detection Yes No 39 NEW YORK INDEPENDENT SYSTEM OPERATOR 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 3 Low frequency oscillation detection Yes No Branch the
52. n the CC s SGI LAN using the UDP IP protocol To minimize latency this packet is sent out as soon as all data for a given time tag has been received or a preset time limit is reached Yes No Additional capabilities supplied include 13 14 15 16 Store time aligned data in SGI Real Time Database for applications to use Yes No Save streamed data in SGI Historian as requested Yes No Disturbance monitor to record a table of data on the PDC disc whenever a power system disturbance is detected by a PDC or PMU Yes No In response to a request from the EMS the service must read the most recent phasor measurements from the data buffer calculate various data quantities such as bus voltage magnitude and relative phase angle between stations and system frequency to send back to the EMS 35 NEW YORK INDEPENDENT SYSTEM OPERATOR 17 Per PMU event capturing trigger create binary files at a configurable location Each file will capture the one minute data contained in the circular buffer at the time of trigger pre trigger data and up to four minutes or more of post trigger data This data will be sent to the Data Management subsystem B 4 2 System Management SM The main task of SM is providing overall equipment functionality within SGI It is expected that the Control Center PDC SM will be integrated with the SGI System Management functions Then EMS SM will be coordinated with the PMN components and subsyst
53. ng Yes No Does the vendor s application include the following real time situation awareness applications optional applications may be deployed later depend upon availability costs and benefits Voltage phase angle monitoring Yes No Voltage stability monitoring Yes No Low frequency oscillation monitoring Yes No Fault location Yes No Island identification optional Yes No Island condition monitoring optional Yes No Small Signal Stability Monitoring optional Yes No mw moeaoge 16 NEW YORK INDEPENDENT SYSTEM OPERATOR 11 12 13 14 15 16 17 18 19 20 21 h Real time thermal line rating monitoring optional Yes No i Distributed Generation DG Independent Power Producer IPP Applications optional Yes No Does the system support data exchange with various ISO entities MISO PJM ISO Reliability Coordination Councils and Transmission and or Generator owners Yes No ISO entities shall be able to request and retrieve real time data stream with data reporting rate and data types that may be different from that used by NYISO SGI Yes No NYISO SGI shall be able to request and retrieve real time data stream with data reporting rate and data types required by NYISO SGI Yes No Are the vendor s applications capable of interoperability of PMUs and DFR PMUs from different suppliers with IEEE C37 118 2005 level 1 steady state performance requir
54. ng NPAM ees esse ee se ee ee ee ee RA GR Re ee ee ee RA GR Re ee 9 3 2 Voltage Stability Monitoring VS sissies Ge sesse Gee Gees ke Ns ee Ge Be ee ee eN Ed id NN 9 3 3 Low Frequency Oscillation Monitoring LFOM esse see se esse ee Ra Ge Re ee ee ee RA ee Re ee 9 34 A dd E EE ao a ENE AE EEE EERE 10 3 5 Post Event Analysis PEA ies ER Gee ee Ge Sen GR DE GN GERS GR Ee Ge ee ede 10 3 6 DEK Records Retrieval ENEE Ge ie De RD ee N Ge GR 11 3 7 Global DER Event Trigger Management ee sis Ee EG Ee GESE Gee SEG se GREG GES SN 11 38 Wid area Event Detection EE 11 3 9 Future Advanced Applic ati Ome re RR EER Re ER ERG ee ees ee n Ge 11 4 0 SGI Cyber Security Requirements see EE N Se dn goe eed ge Gee N ES De ee 11 5 0 REI Response Instr eons eegener 11 2 NEE EE 11 NEW YORK INDEPENDENT SYSTEM OPERATOR 52 RED Skedule SE Ge Ge GR ee ee ed ee 11 3 23 RFI Response Format sissien ieena eed ee Se euer 12 5 3 1 Cover Lett eare esa REEE EE E eN A E A TEE ERT 12 53 2 Resp ns s E cas sascuscessutuweadabcuninvsaionspancwasesiesuutasulbsuwadmpsascenssasiscussctuiiensees 12 5 3 3 Re sponse Gie eee eee N ee 12 54 Doc mentation d tente De Ge Ge Re AEEA pg es Ge DS Doe ge 12 St Nee 12 Appendix As Response QUESOS ses Ee EE Ee bg Se Gee ses EG REGS N N ER rg 13 ya C EE e 13 A 2 PMN System Requirements Summary eieiei Geer 13 e WE EE 14 AA SGI System Requirements for Current Deplovment esse se ee ee ee ee Re ee ee 15 A 5 SGI System R
55. o Global DFR Event Trigger Management A wide variety of triggers should be available to initiate event recording Yes No The system should have various input analog modules to interface to signal sources Modules connected to standard signals at the substation are normally 52 NEW YORK INDEPENDENT SYSTEM OPERATOR a Secondary AC voltage Yes No b Secondary AC current Yes No c Low level DC voltage and current signals Yes No 3 The GUI software should available to configure the trigger management system to accept these signals Yes No C 8 Wide Area Event Detection WED Wide area event detection is a part of situational awareness particularly in the knowledge of device statuses both locally and over the wide area Detecting and identifying significant switching events on the system can help system dispatchers understand and react to problems on the grid The WED application should be functionally designed to accommodate at a minimum the following 1 Measurable quantities that can be used for wide area event detection should include a Line impedances and ratings Yes No b Pre event and wide area topology information from the NERC System Data Exchange NERC SDX Yes No 2 Wide area measurements from PMUs a Wide area events detection must be capable to what change in angles will be used in power flow equations ability to detect single and double line outages Yes No b The detection process shou
56. onsist of tools to do modal analysis offline with historical data model validation in linear domain and other linear analysis tools Yes No The application should be user friendly with helping tools and straight forward to operate Yes No The online outputs should be functionally defined by the following 9 10 11 12 13 14 15 16 17 Oscillation magnitude frequency of oscillation and corresponding damping of each mode within the specified frequency range for the selected measurement Yes No Polar diagrams Yes No Strip charts Yes No Bar charts with different colors for different modes Yes No Continuous visual display of movement of the modes in complex plane Yes No Display of the amplitude frequency of oscillation and corresponding damping for the selected measurements at selected locations as a trend Yes No Display of minimum damping criteria to be provided by NYISO in different plots Yes No Online warning and emergency alerting for lower than minimum damping Yes No Any combinations of above can be selected for multiview display Yes No The off line output capabilities include 18 19 20 21 Access to historical data Yes No Data export to business applications such as EXCEL Yes No Data export to csv format and text format Yes No MATLAB interface Yes No 49 NEW YORK INDEPENDENT SYSTEM OPERATOR The event management function should provide 22
57. orage to directly support SGI operations and applications Yes No 137 The data retention for this historian is a minimum of X year online Yes No 138 Fault tolerance can be provided in various ways but must be compatible with the inter site failover architecture Yes No 43 NEW YORK INDEPENDENT SYSTEM OPERATOR There is also a requirement for long term X year storage for the corporate users Se shall service SGI users and a number of non SGI users while ensuring that the security and performance of the other component systems of the SGI are not impacted Yes No B 4 8 External Data Proxy Services EDPS External data proxy services subscribe to weather traffic earthquake fire and lightning indicator data provider sites It retrieves synchronizes and provides these data to be stored in both Real Time and Historian SGI databases Vendor system should confirm to minimum requirements stated below EDPS Input 140 Request from Data Management to subscribe to and retrieve weather traffic earthquake fire and lightning indicator data from provider sites The procedure will be similar to current NYISO subscription and data retrieval to ISO OASIS via certified URL Yes No 141 Weather traffic earthquake fire and lightning indicator data from provider sites Yes No EDPS Output 142 Weather traffic earthquake fire and lightning indicator data per zone to SGI Real Time data base Yes No 143 ISO publi
58. orities and responsibilities for conduct of tests and approval of test results Yes No Description of test equipment Yes No Listing of all data to be observed and recorded Yes No 60 NEW YORK INDEPENDENT SYSTEM OPERATOR Supplemental A Communication Protocols To be completed when additional information is provided by NYISO The following describes the data communication protocols currently in use throughout the industry Note that this list of protocols is subject to change considering the Smart Grid Architecture blueprint and the SGI requirements discussed in this System Design document Communication Requirements General The major requirements are p P Nn 6 7 Interoperability Open Data Access Remote Control Self Defining Devices Automated Reports Substation Events Handling Time Sync Network Management Security Integrity Expandability Extensibility Easy of Maintainability Independent Functional Structure Media_Transmission Applications Protective Function Response Time Capability Peer to peer communications Following is a list of required protocols Although Object Oriented Protocol technologies lack established standards the design must be open to adapt such technologies Products can communicate over Generic Object Oriented Substation GOOSE Yes No Products can communicate over OPC Yes No Products can communicate over ModBus Yes No Products
59. peed communication channel to a central location where a Phasor Data Concentrator PDC collects the data from all the PMUs and redistributes the time aligned data Yes No To ensure the continuity and reliability of receiving PMU data stream each PMU streamed data must be sent to two locations via two different communication channels Yes No PMU Input 22 NEW YORK INDEPENDENT SYSTEM OPERATOR 9 PM functions should at a minimum be able to receive voltages and currents for 3 phases from a number of PTs and CTs and breaker status bits through digital words Yes No 10 As a real time phasor measurement instrument the PMU should be able to both transmit and or receive phasor data to from remote locations for comparison with local phasors Yes No PMU Output 11 PMU computes the positive sequence voltage and current phasors The computed data is then transmitted on a very high speed communication channel to a Master Station MS Phasor Data Concentrator labeled as the PDAC at a central location 12 Many current PMUs use the Macrodyne format but the majority uses the IEEE C37 118 format Current PMUs measure ten or fewer phasors and up to two digitals 13 Vendors must conform to the following criteria for maximum PMU output data rate calculation using IEEE C37 118 2005 a All data will be in floating point format Yes No b Ten phasors and two digital words will be transmitted Yes No c Data transmiss
60. please describe how this is achieved e g GPS IEEE 1588 and list the use of the system clock in various functions and applications of the product If using specialized hardware does the product also support other data communication methods such as serial data ports Data Input Capabilities 30 Does the product support receiving phasor data in IEEE C37 118 2005 data frame protocol 31 Does the product support receiving phasor data in other data protocols such as proprietary data protocols IEC 61850 IEEE 1344 etc If yes please describe each of the data protocol supported 32 Does the product support receiving phasor data in either TCP IP and or UDP IP data packets 33 If the product supports receiving data in UDP IP packets does the product support receiving phasor data sent by PMUs PDCs in either a unicast IP address or a multicast IP address If yes please describe how receiving multicast UDP IP data is accomplished 34 If the product is a general data concentrator does the product use other protocols to receive phasor non phasor data in addition to phasor data protocols C37 118 61850 35 Is there a limit on how many real time phasor data streams that the product can receive from PMUs 29 NEW YORK INDEPENDENT SYSTEM OPERATOR B 3 5 36 37 38 39 Is there a limit on the highest receiving phasor data rate 30 60 120 or higher that the product can support Are the above two limits affected
61. plication need RTU data What algorithm is used to identify the dynamic parameters of the NYISO model Can the application be run in real time Does the application need any data from other applications What communication protocol is used to exchange data between applications What is the cost of the application module What are the license terms and conditions How frequent is an upgrade available What are the inputs and outputs of the application 56 NEW YORK INDEPENDENT SYSTEM OPERATOR Appendix D Capacitor Equipment The focus of the questions in this section is to provide the latest understanding of controllers and associated software for Smart Grid enabled capacitors 1 2 10 11 12 13 14 15 16 17 Describe the capacitor control products along with the associated software Are the controllers designed to handle Distribution pole or pad mounted or station or Transmission station connected capacitors Does the controller meet the cyber security requirements Hardened Describe the command and control functions Describe the communication capability technologies and protocol options supported Single two way or both Is the controller and communications separate or a single device What is the voltage required to run the communications Do you envision connecting directly to a PDC Is the device remotely controllable If yes can the device be remotely overwritten Fo
62. producing a synchrophasor as defined by the IEEE standard C37 118 2005 Such devices may include PMUs Phasor Measurement Units or SMUs Synchronized Measurement Units They may also include NEW YORK INDEPENDENT SYSTEM OPERATOR DFRs Digital Fault Recorders or conventional relays that are enabled to make such synchronized measurements The main purpose of the phasor measurement technology is to make simultaneous synchronized measurements of system variables such as voltages currents and their associated angles over a widely separated network to permit an accurate view of the entire system In the absence of this technology local measurements of power systems quantities or unsynchronized measurements of remote quantities do not generally allow an accurate picture of the state of the system This prevents implementation of accurate remedies to evolving wide area events With an accurate picture of the entire system due to synchronized measurements and fast data networks better remedies can be implemented and the overall stability reliability of the network can be improved 242 Phasor Data Concentrator PDC Function PDCs are devices that collect synchrophasor data from PME and collate align them for transmission to control centers Typically a PDC would be installed in a substation so that the synchrophasor data from all of the PME in a substation would be sent as one data packet to the control center Without the PDC the control
63. r example the capacitor can be set to switch on and off based on a voltage or current or reactive set point Can the set point be over written over ridden or re programmed remotely Are any sensors required on pole or pad mounted capacitors If yes please describe How is the status of the capacitor switch confirmed Is the product upgradable Hardware and Software Describe the data access logging and graphic capability How is bad data dealt with and or adjusted Describe the mounting options How many capacitors banks can be supported with a single controller Describe the set up and configuration process What is the lead time to acquire product Can the input and output of the controller be integrated with other transmission and distribution capacitor controllers 57 NEW YORK INDEPENDENT SYSTEM OPERATOR Appendix E Cyber Security l 10 11 12 13 14 Has your company done any business with either the US Federal Government or State Government a Specifically have you done business with either the US DoE or DOD to provide any Smart Grid technologies What industry federal or technical standards are your products currently compliant with How do you assure that your products remain compliant with industry federal or technical standards Do you participate in any of the standards bodies NIST IEEE IEC etc What safeguarding procedures are deployed within your manufact
64. r isolating a faulted line may disconnect customers and reduce the system s transfer capability Thus this should be restricted to affect as few customers as possible and for as short a time as possible Fast and reliable fault location can assist the fast repair and restoration of an isolated line This application is for quickly and accurately identifying and locating a fault after it occurs SGI shall provide a suite of power system FL functions The FL functions comprise a set of tools for faulted lines identification and accurate fault location calculations The FL functions are post fault analysis applications The FL application should be functionally designed to accommodate at a minimum the following 3 5 Post Event Analysis PEA An event is an abnormal situation in the power system that may create an abnormal voltage current or power flow change in different buses or nodes in the system The event can be due to a temporary or a permanent fault a switching event such as capacitor switching abnormal loading generation surplus or deficiency etc The PEA application shall allow the user to identify locate and analyze an abnormal situation from recent historical recorded data It allows a replay of event data for a specified time span It should allow different analyses to be performed simultaneously on the data available in the database and should have the ability to identify any event from recorded data to isolate the time span when
65. rements of the current draft C37 118 will be C37 118 1 standard Does phasor measurement performance at 120 frames s meet class P and M requirements of the current draft C37 118 will be C37 118 1 standard by adjusting the requirements to 120 frames s Has it implemented all messaging frames defined in C37 118 2005 Are all time quality related flags defined in C37 118 2005 supported Does the device use an internal GPS receiver Does the device support IEEE 1588 Does the device use external timing source If external timing source is used will the device be able to determine if the timing source is synchronized to UTC If IEEE 1588 is supported will the device be able to determine if the master clock is synchronized to UTC When the synchronization to UTC is lost will the device be able to positively determine the timing accuracy of its internal clock to UTC Does the device provide at least two Ethernet ports 25 NEW YORK INDEPENDENT SYSTEM OPERATOR 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 Does the device provide options for using either galvanic or optical Ethernet port connector Does the device support both IPv4 and IPv6 for phasor data communication Does the device support using both TCP IP and UDP IP for phasor data and messaging communication Can the device be configured for sending phasor data using UDP IP and other mes
66. rmal limit violation Yes No Branch flow violation Yes No Phase angle and frequency deviation Yes No Island detection Yes No PMU measurement versus SCADA data validation Yes No Compliance Report Generation Yes No DFR recording initiation for selected areas or global Yes No Network model validation Yes No Creating the stream files for post disturbance analysis dst Format Yes No Replaying or playing back previous recorded stream files in dst format The play back option must allow for a review of a specific time frame where an event happened Yes No Produce meaningful plots tables charts and analysis of power transmission system conditions Yes No The capability to select which quantities to show must be provided Yes No The length of the plots must be selectable Yes No The program could be set to continuously record data on disc over a number of hours limited by disc space Yes No Flow Gates and Interface Monitoring Yes No Automated daily or weekly report generation with emailing capability providing summary information on Yes No PMU PDC performance overall summary and by individual PMUs Yes No Number of alarms by alarming category criteria and region Yes No Frequency trends and statistics max min average and specific patterns Yes No Angle difference Max min and average between regions during peak and off peak times Yes No 40 NEW YORK INDEPENDENT SYSTEM OPERAT
67. s and as a memory buffer to prevent data loss in case of temporary communication failures Yes No b Real time data imbedded with the SGI applications to provide the necessary performance of the applications Yes No C Online historical data to facilitate fast and secure access to historical data for planning engineering and operation analysis such as post disturbance investigations Yes No d Offline historical data archive to keep data over long period of time without affecting the data access performance of the online historical data store Yes No A 4 SGI System Requirements for Current Deployment The system requirements for SGI initial deployment i e within the scope of the initial RFP can be summarized as follows 1 Is the vendor able to supply production grade Control Center Systems CCS at control centers that include PDAC application servers visualization and presentation servers and data storage and archiving subsystems Yes No 2 Does the vendor have capability to install SGI in four computing environments a Dispatcher Training System and or Production including cluster or failover backup systems Yes No b Development Yes No c Testing Yes No d Staging System Test Training Yes No 3 Can the vendor provide reliable high speed communication network between DFR PMU and PDAC Yes No What is the expected communication speed envisioned by the vendor 15 NEW YORK INDEPENDENT SYST
68. saging using TCP IP Does the device support sending phasor data to either unicast or multicast IP address Can user configure the multicast IP address to be used Does the device include a feature to send multiple phasor data frames in one IP packet If the device include a feature to send multiple phasor data frames in one IP packet can user configure how many frames to be included Does the device support OPC protocols If yes how it is implemented and used Does the device support 61850 protocols If yes how it is implemented and used Which specific parts of the standard are supported Does the device support DNP protocols If yes how it is implemented and used Does the device support any other data and messaging protocols If yes please explain each of them Does the device support generate more than one phasor data stream If supporting more than one data stream can each data stream be configured independently by user Does the PMU provide any internal data storage for phasor measurement data Has the device been tested to meet all electrical electromagnetic compatibility environmental standards for substation equipment If it has please provide test report certification for each test Does the device support the use of all types of substation DC supply voltages in US Does the device provide a minimum of 200 ms power failure bridging time without an internal battery 26 68 NEW YORK INDEPENDENT SY
69. shed data from OASIS ADS and CMRI may also be retrieved and stored Yes No EDPS Services 144 Periodic data request to weather traffic earthquake fire and lightning indicator data provider sites Yes No 145 Retrieving weather traffic earthquake fire and lightning indicator data Yes No 146 Managing and synchronizing received data per defined zones Yes No B 4 9 External Systems Following are key external systems with which SGI is expected to be interfaced External PDCs EPDC 147 External PDCs are owned by generation transmission external ISO PEPMs and other ISO PDCs which by agreement must be able to provide streamed synchrophasor 44 NEW YORK INDEPENDENT SYSTEM OPERATOR PMU data to PDAC at a rate of 30 samples per second in IEEE C37 118 2005 format Yes No 148 External PDACs PDCs must be able to receive streamed synchrophasor data from PDAC by agreement at a rate of 30 samples per second in IEEE C37 118 2005 format Yes No 149 External PDCs must be able to communicate with PDAC directly through a planned ISOnet or through NASPInet if available using a Phasor Gateway installed at NYISO GCC Yes No EPDC Input The number of streamed data input from EPDCs depends on the number of EPDCs connected to the ISOnet or NASPInet that NYISO has agreement with Each EPDC shall send only one data stream to PDAC in IEEE C37 118 2005 format Data volume for each EPDC is determined by the number of PM
70. some event has taken place It analyzes the recorded data of voltage current magnitudes phase angles at different buses breaker operations etc to generate user specified identification of events It helps to identify the precise time at which the abnormal event occurred and the sequence of preceding events leading to determining the cause of the incidence Hence it could provide some information on how the situation could have been averted Faults and other disturbances are typical for a power system Although they can t be avoided the attempt is to devise a system so that these disturbances do not create a critical failure thereby preventing power delivery to the customer PEA can provide an insight into the problems that the system may have had leading to the incidence The analysis 10 NEW YORK INDEPENDENT SYSTEM OPERATOR helps to identify those problems and can help to mitigate and prevent those problems in the future 3 6 DFR Records Retrieval DFRRR The records of phasor measurements associated with any DFR should be accessible through the Data Management subsystem 3 7 Global DFR Event Trigger Management The records of phasor measurements associated with any predefined global event should be accessible through the Data Management subsystem 38 Wide area Event Detection The occurrence of any event predefined as a wide area event should be accessible through the Data Management subsystem 3 9 Future Advanced Applicat
71. sor data stream be configured independently for amount of data to be included the reporting data rate to be used and so on Does the product have a function to pack several data frames of an output data stream into one IP data packet If the product has a function to pack several data frames of a data stream into one IP data packet does the product allow users to configure how many data frames in a phasor data stream e g an IEEE C37 118 2005 data stream that can be sent in one IP data packet Can the product create output data streams that maintain original PMU PDC data frame configurations from each PMU PDC device If yes please describe how this is accomplished and the data protocol used Can the product create output data streams that do not maintain the same PMU PDC data frame configurations of each PMU PDC device If yes please describe how this is accomplished and the data protocol used If the product is a general data concentrator does the product use any other protocols to receive output phasor non phasor data in addition to phasor data protocols C37 118 61850 33 NEW YORK INDEPENDENT SYSTEM OPERATOR 86 Is there a limit on how many real time phasor data streams that the product can output 87 Is there a limit on the highest output phasor data rate 30 60 120 or higher that the product can support 88 Are the above two limits affected by the size of data packet of the phasor data streams that it outputs
72. t DM The main task of the Data Management is providing data retrieval data validation data storage and data delivery services within SGI not only for the existing EMS but also for all of the added PMN subsystems DM Input 35 Time aligned PMU data from PDAC in IEEE C37 118 2005 format Yes No 36 DFR data from DFR PMUs in COMTRADE format Yes No 37 Applications data output TBD Yes No 38 External data Proxy server outputs earthquake fire traffic and weather Yes No 39 Real Time Data requested by applications Yes No 40 Grid network data for EMS Yes No 41 EMS Historian output Yes No DM Output 42 Validated and quality checked time aligned PMU data stream in IEEE C37 118 2005 format Yes No 43 Validated and quality checked external proxy data Yes No 44 Pass through EMS data Yes No 45 Pass through application output data Yes No DM Services Data Retrieval via GCC SGI LAN and SGI WAN 37 NEW YORK INDEPENDENT SYSTEM OPERATOR 47 48 49 50 51 52 53 54 33 56 KR 58 59 60 6l 62 63 B 4 4 6 Retrieves and validates PMUs synchrophasor data from PDAC Yes No Retrieves and validates fault and event recording data from DFRs unless there are PDCs commercially available Yes No Retrieves external Proxy data earthquake fire traffic and weather Yes No Data Storage via GCC SGI LAN Yes No Stores DFRs recorded data in SGI Histori
73. t format and to MATLAB Yes No PMU measurements should be Global Positioning System GPS synchronized at both ends of the lines to deliver values in real time This should provide voltage and current phasor information at both ends of the line for System Dispatchers along with calculated values for active reactive power flow and the direction of the applicable power flow 47 NEW YORK INDEPENDENT SYSTEM OPERATOR The online output should provide 4 of 6 10 11 12 13 Display of PV curve with indication of actual loading point Yes No Voltage and current monitoring along a flowgate Yes No Calculation and display of actual power margin Yes No Display of the voltage and current phasors at both ends of the transmission corridor Yes No Display of natural loading point and nominal loading point Yes No Display of the actual active and reactive power flow Yes No Display of the direction of the active power transmitted through a corridor Yes No Display of the equivalent impedance of the load area Yes No Data logging and trend display Yes No Online warnings and alarms Yes No Offline should provide 14 15 C 3 Access to historical data Yes No Data export to business applications such as EXCEL Yes No Low Frequency Oscillation Monitoring LFOM The detection and display of low frequency oscillation in the system is to be supplied by the application vendor This helps in
74. t storage for long term event archive Yes No 24 Can the SGI data be enabled to use multiple vendor application software visualization advanced network applications voltage support equipment monitoring and control fault locator etc Yes No 25 Can the communication between PDAC and EMS SCADA Supervisory Control and Data Acquisition system be through ICCP protocol Yes No 26 Can the system allow for communication channel interruption of up to 1 hour for long term system dynamics recording Yes No 27 Can the vendor s system accommodate the following a The system shall be able to accommodate PMU devices reporting rate up to 60 samples per second Yes No b The system shall allow manual and automatic global triggering of DFR data recording Yes No c The CCS shall be able to retrieve and store recorded PMU data from DFR PMU Yes No d The CCS shall be able to retrieve and store recorded DFR data typical total recording length 10 to 1200 seconds from DFR PMU Yes No e DFRs record at a sample rate of 100 to 120 samples per second Yes No f Pre fault time 2 to 600 seconds Yes No g Post fault time 4 to 300 seconds Yes No h Recording time after end of triggers 2 to 120 seconds Yes No i The system shall be secure by default with all security features enabled in the standard installation configuration Yes No 28 Does the system support a minimum security feature set including a Remote config
75. tation Any documentation submitted as a response to this RFI shall become NYISO property and will not be returned Any proprietary or confidential information provided by respondents to this RFI should be clearly labeled as such to prevent disclosure 55 No Commitment Neither this request for information nor any other written or oral information made available to any potential bidder or any other person or party or their respective representatives agents or advisors form the basis of any offer or contract Rather any information regarding the project or any part thereof will give rise to contractual obligations only if and when final agreements have been executed in writing by the parties thereto Small businesses minority owned and women owned firms are encouraged to respond to this request for information and larger firms are encouraged to associate with small businesses minority owned and women owned firms NYISO will not reimburse responders for expenses that are incurred as a result of responding to this RFI 12 NEW YORK INDEPENDENT SYSTEM OPERATOR Appendix A Response Questions The respondent is to address all of the issues identified in the previous sections The respondent is to answer the following questions with as much detail as possible The respondent is to ensure that answers provided are relevant to the Project List specific projects and provide details on that project when appropriate to the previous conc
76. tem DNP Distributed network protocol DOE Department of energy USA DR Demand response DSM Demand side management DW Data warehousing EDPS External data proxy services EMS Energy management system EPDC External PDC PDCs that are external to NYISO that could share synchrophasor data with NYISO FL Fault location GCC Grid control center GCCN The dedicated communication network for the NYISO Grid Control Center GIS Geospatial Information System GOOSE Generic Object Oriented Substation Events GPS Global Positioning System 62 NEW YORK INDEPENDENT SYSTEM OPERATOR Acronym Description GUI Graphical User Interface HDS Historian data server HMAC Hash message authentication code HMI Human Machine Interface HTTP Hyper Text Transfer Protocol ICCP Inter control center protocol IED Intelligent electronics devices such as digital relays IEEE C37 118 IEEE standard for synchrophasors for power systems IP Internet protocol IP Intellectual property IPP Independent power producer IPv4 Internet Protocol version 4 Ipv6 Internet Protocol version 6 LFOM Low Frequency Oscillation Monitoring LIPA Long Island Power Authority MD3i Model Driven Information Integration and Intelligence Xtensible methodology MPLS Multiprotocol Label Switching a mechanism in high performan
77. the time alignment function provide a user configurable waiting time setting used for waiting input data packets with the same time tag to arrive before the time alignment to start Will the input data packets that arrived after the waiting time be discarded Does your product provide a pack and go function i e multiple input PMU data packets are only packed into one IP packet and send out without any time alignment or other data processing performed 30 NEW YORK INDEPENDENT SYSTEM OPERATOR B 3 6 B 3 7 47 Does the down sampling function changing phasor data rate from a high one to a lower one e g from 60 fps to 30 fps of your product use the simple skip the point method 48 Does the down sampling function of your product involve filtering If yes please describe how the down sampling is accomplished 49 Does the product perform certain data validation for received data If yes describe what types of validations are performed and how they are performed 50 Does the product include a data error handling function If yes please describe what types of data errors that it handles and how these errors are handled 51 Does the product include a QoS latency interruptions etc monitoring function for received data streams If yes please describe how this function works Data Storage and Retrieval Capabilities 52 Does the product include a data storage and retrieval function If yes please describe how the
78. ther ISOs RTOs Els etc Does the system support the following applications at NYISO s control center a Situational awareness and visualization b Voltage stability monitoring 13 NEW YORK INDEPENDENT SYSTEM OPERATOR 6 AA c State estimation update at the EMS level d Calibration of system planning and operations models and e Controlled system separation Is the system architecture flexible to support easy addition of future applications General SGI System Requirements The vendor is to identify by an answer of Yes No or a more detailed response if the future proposed offering will satisfy the following general SGI system requirements l SGI including DFR PMU PDAC situation awareness applications shall be a production system with full vendor support Yes No SGI shall be a highly reliable and secure system with backup redundancies The system shall continue to function in the case of any single point location of failure Yes No The PDAC databases and SGI applications software shall be able to support NYISO operations at either main CC or backup CC locations of NYISO Yes No The PDAC databases and SGI applications software should satisfy the following requirements a They shall be able to accommodate gradually increased number and types of phasor measurement devices Yes No b They shall be able to accommodate gradually increased amount of external phasor measurement data exchanges
79. ther or not they can supply the devices with the following minimum functionalities 1 The DFR function should be able to record data simultaneously in three time domains high speed transient fault minimum 7860 samples second up to 60 seconds low speed long term dynamic swing 760 samples second for up to 16 minutes and continuous trend as per NERC PRC 002 RFC 1 at 30 samples second for up to 30 days Yes No 2 The digital fault recorder function should have the capability of sending output files in COMTRADE format and either manually or automatically uploading output files to the PDAC Information on the COMTRADE format is available in IEEE C37 111 1999 TEEE Standard for Common Format for Transient Data Exchange COMTRADE for Power Systems or its successor standard Yes No 3 Data files are to be named in conformance with IEEE C37 232 Recommended Practice for Naming Time Sequence Data Files Yes No 4 Wide varieties of triggers should be available to initiate transient and long term recordings such as faults manual and automatic requests Yes No 20 NEW YORK INDEPENDENT SYSTEM OPERATOR 5 Fault and event recording data should be sent either automatically from the DFR PMU Units to the System and Data Management SDM servers upon the occurrence of any local or globally triggered event or upon request and it will be stored in the SGI Real time and Historian database after data validation Yes No
80. tion and control functions such as substation state estimator substation backup protection etc If yes please describe each application function 73 Are all supporting system applications alarm functions and or substation monitoring protection and control functions running on the same processing unit as the data 32 NEW YORK INDEPENDENT SYSTEM OPERATOR concentration functions If not please describe how these are running on different processing units and how they interface with each other B 3 10 Data Output Capabilities 74 75 76 71 78 79 80 81 82 83 84 85 Does the product support sending streaming phasor data in IEEE C37 118 2005 data frame protocol Does the product support sending streaming phasor data in other data protocols such as proprietary data protocols IEC 61850 IEEE 1344 OPC DNP etc Does the product support sending phasor data in either TCP IP and or UDP IP data packets If support sending data in UDP IP packets does the product support sending phasor data in either an unicast IP address or a multicast IP address If support sending data in UDP IP packets does the product allow users to configure the destination IP address be it a unicast or a multicast IP address Is the product support generating and sending multiple phasor data streams that are different from each other data rate number of measurement data included etc Can each output pha
81. tions and so on If yes please provide detailed description of the system Is this a software only product meaning that it can run on any off the shelf standardized hardware and operating systems that meet its specifications If it is a software only product can it run on a MS Windows server system If it is a software only product can it run on a Linux server system If it is a software only product can it run on other types of server systems such as server clusters cloud computing environment etc Please list all other supported server systems 28 NEW YORK INDEPENDENT SYSTEM OPERATOR B 3 3 B 3 4 23 If it is not a software only product can the specialized hardware be supplied by more than one supplier 24 Does the product support system redundancy design similar to that of a production grade EMS SCADA system If yes please provide a detailed description how the product can be used in a redundant system design Communication Networking Capability 25 Does the product support at least two four Ethernet ports for data input and output 26 If using specialized hardware does the product support both optical and galvanic connectors for its Ethernet ports 27 If using specialized hardware does the product support at least 1000Mbps 28 If using specialized hardware does the product support both IPv4 and IPv6 29 Does the product have an accurate system clock that is synced to be within 1 uS to UTC If yes
82. ty The wide area situational awareness applications that need to be supported by Vendor s application in the current deployment must include the following Voltage phase angle monitoring Voltage stability monitoring Low frequency oscillation monitoring Fault location and Post event analysis application In addition a number of supporting applications may be included in the current deployment 1 DFR records retrieval application Global DFR event trigger management application Wide area event detection application All situation awareness applications shall support the following basic functionalities 1 Warnings and alarms generation Trending Compliance reporting NEW YORK INDEPENDENT SYSTEM OPERATOR The applications that need to be supported are listed in the following subsections 31 Voltage Phase Angle Monitoring VPAM The voltage phase angle differences between different buses are important system parameters They are accurate indicators of power flow and system stability Real time monitoring of these parameters should be a significant contributor towards corrective actions This application allows the user to monitor the phase angle differences between multiple buses and a selectable reference bus in the system where PMUs are installed The application should generate warnings alarms for the monitored voltage phase angle differences when preset limits are exceeded 32 Voltage Stability Monitoring VSM Voltage
83. uration via secure protocol per reference Yes No b Account management per reference Yes No c Authentication per reference Yes No d Authorization per reference Yes No e Auditing per reference Yes No f All relevant NYISO Information Technology Security ITS policies and standards per references Yes No 18 A 5 NEW YORK INDEPENDENT SYSTEM OPERATOR SGI System Requirements for Future Expansion Integration It may not be possible to list all system requirements for SGI future expansion integration A few anticipated requirements are summarized as follows The vendors are requested to provide a Yes No answer to the following functionalities 1 Capable of supporting future PMUs and DFR PMUs deployment in up to 500 NYISO substations and data exchange with up to 500 external substations Yes No PMUs and DFR PMU shall be able to support multiple data and messaging protocols such as updated IEEE C37 118 data frame protocol IEC 61850 UCA GOOSE messaging standards DNP 3 0 and OPC and possibly other protocols for interaction integration with other devices systems Yes No PDAC shall be able to support multiple data and messaging protocols for interacting with various monitoring protection and control IEDs Yes No SGI shall be able to support multiple data and messaging protocols for interacting with other NYISO systems Yes No The system shall be able to support high speed tens of millise
84. uring that can provide assurance that individual components of your product are not tampered or compromised by your supply chain What is your schedule for standard release time frames for security patches and firmware upgrades What safeguarding procedures do you have in place regarding personnel background checks What types of maintenance support agreements do you provide customers What encryption mechanisms are available within your products for data as it s transferred and at rest Please provide a description of the remote access centralized management capabilities of your products What kinds of authentication mechanisms are available within your product What kind of authorization and roles based access is supported by your products Does your product support event notification or alerting to commonly used Security Event Incident Management SEIM products What kinds of logging formats are available within your products 58 NEW YORK INDEPENDENT SYSTEM OPERATOR Appendix F Testing l Can the supplier provide detailed tests plan s including all simulation design verification tests if applicable factory tests site acceptance tests and commissioning tests Yes No Is it possible to have all inspection and test procedures agreed upon before PO Yes No Are the tests comprehensive enough to prove compliance with all technical requirements Yes No Will the supplier provide inspection and test
85. ust also be fully configurable These inputs are but not limited to number of phasors number of digital status words reporting rates number of status bytes and format data Yes No 34 NEW YORK INDEPENDENT SYSTEM OPERATOR PDAC Output 7 9 PDAC shall multicast correlated PMUs and other PDCs data to a specific port over a specific subnet to be readable to all subsystems on that subnet Yes No Time aligned phasor data from all PMUs shall be streamed out at the same rate 30 frames per second to NYISO GCC s SGI LAN where SGI Real Time database Visualization servers VSs and Historians are connected Yes No Received DFR data must able to be sent to NYISO GCC s SGI LAN where SGI Real Time database VSs DFR data analysis application servers and DFR data Historians are connected Yes No PDAC Services Does PDAC provide the following services 10 11 12 Receive and process data from an initial 160 PMUs 80 NYISOs own DFR PMUs plus 80 equivalent external PMUs through external PDCs with an estimate of over 1 000 PMUs by 2020 500 NYISO s own DFR PMU and PMUs and 500 external standalone and integrated PMUs each PMU pushes data out at a maximum rate of 24 480 bits sec Yes No Receive and process data from multiple ISO PDCs between 10 to 20 PDCs for an initial equivalent external 80 PMUs Yes No Time align the PMUs and PDCs data from all inputs and stream out the time align phasor data o
86. xtract the magnitude and phase information for different quantities like voltage and current or any other quantities separately Yes No The calculation of phase difference between two such data sources can be selected by the System Dispatcher The application routine would calculate the difference in the phase angles between the selected bus data and store in appropriate register to be accessed by other programs for visual display in the control center or stored in a real time database Yes No The application should be capable of converting between degree and radian from the selection of operator The maximum and minimum phase angle differences are to be specified as input from the operator The maximum and minimum phase angle differences are to be used in the application to identify potential angle stability problem Yes No Provisions should be made to be selected by operators to either observe phase angle differences of voltages or currents at each sampling period or every N data points where N will be specified by NYISO This down sampling may be done with filters or without any filter Yes No The objective of voltage phase angle monitoring will be to provide sufficient information to the System Dispatcher to evaluate the present angle differences between two selected locations The voltage phase angle monitoring application must have the ability to deliver real time voltage angle monitoring with alarms and on line off line visuali
87. zation features such as 6 7 8 9 Phase angle difference between selected measurement locations Yes No Topological phasor display Yes No Polar diagrams Yes No Strip charts Yes No 46 NEW YORK INDEPENDENT SYSTEM OPERATOR 10 Any combination of above outputs Yes No 11 The real time output should provide a Display of phase angle difference between selected locations in real time Yes No b Display of the phase angle curve at selected locations as a trend Yes No c Display of the maximum acceptable phase angle between two selected locations Yes No d Online warning and emergency alerting Yes No 12 The off line output should provide a Access to historical data Yes No b Data export to business applications such as EXCEL Yes No 13 For events a Angle difference should be included as part of on line warnings and alarms Yes No C 2 Voltage Stability Monitoring VSM The objective of voltage stability monitoring is to have the ability to assess the present power margin with respect to voltage stability The VSM application should be functionally defined by the following 1 Monitor the PV and QV curves with respect to a Actual loading Yes No b Point of maximum loadability Yes No c Power margin Yes No 2 Provisions should be in the application to calculate Thevenin equivalent impedance and load impedance Yes No 3 Extraction of Jacobians for PV and QV calculations to tex

Download Pdf Manuals

Related Search

Related Contents

  TAW 200  Kenroy Home 32424MOB Instructions / Assembly  取扱説明書（PDF）  Consulter le programme  Istruzioni per l`uso  Blackmagic Audio Monitor  Inversor/carregador Conext™ XW  Guia do Usuário  Cartographie missions DDPP  

Copyright © All rights reserved. Failed to retrieve file